ABB REF630 User manual

Brand: ABB

Model: REF630

Type: User manual

Relion

630 series

Feeder Protection and Control

REF630

Product Guide

Contents

1. Description...........................................................3

2. Application...........................................................3

3. Preconfigurations.................................................5

4. Protection functions.............................................8

5. Control................................................................12

6. Fault location......................................................12

7. Measurement.....................................................12

8. Disturbance recorder..........................................12

9. Event log.............................................................13

10. Disturbance report............................................13

11. Circuit-breaker monitoring................................13

12. Trip-circuit supervision......................................13

13. Self-supervision.................................................14

14. Fuse failure supervision.....................................14

15. Current circuit supervision................................14

16. Access control...................................................14

17. Inputs and outputs............................................14

18. Communication.................................................15

19. Technical data...................................................16

20. Front panel user interface.................................61

21. Mounting methods............................................61

22. Selection and ordering data..............................63

23. Accessories.......................................................67

24. Tools..................................................................68

25. Supported ABB solutions..................................69

26. Terminal diagram...............................................70

27. References........................................................73

28. Functions, codes and symbols.........................73

29. Document revision history.................................76

Disclaimer

The information in this document is subject to change without notice and should not be construed as a commitment by ABB Oy. ABB Oy assumes

no responsibility for any errors that may appear in this document.

Trademarks

ABB and Relion are registered trademarks of ABB Group. All other brand or product names mentioned in this document may be trademarks or

registered trademarks of their respective holders.

Feeder Protection and Control 1MRS756380 A

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1. Description

REF630 is a comprehensive feeder

management IED for protection, control,

measuring and supervision of utility and

industrial distribution substations. REF630 is

a member of ABB’s Relion

product family

and a part of its 630 protection and control

product series characterized by functional

scalability and flexible configurability.

REF630 also features necessary control

functions constituting an ideal solution for

feeder bay control.

The 630 series IEDs support the new IEC

61850 substation automation standard

including horizontal GOOSE communication

and the DNP3 communication protocol

offering seamless connectivity to station

automation and SCADA systems.

2. Application

REF630 provides main protection for

overhead lines and cable feeders of

distribution networks. The IED fits both

isolated neutral networks and networks with

resistance or impedance earthed neutral. Four

pre-defined configurations to match typical

feeder protection and control requirements

are available. The pre-defined configurations

can be used as such or easily adapted or

extended with freely selectable add-on

functions, by means of which the IED can be

fine-tuned to exactly satisfy the specific

requirements of your present application.

Feeder Protection and Control 1MRS756380 A

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ABB 3

GUID-EBE462A5-7366-467A-BA18-583E75428EDB V1 EN

Figure 1. RET630 and REF630 IEDs applied for the incoming feeder and primary switchgear

in a double busbar arrangement. The RET630 with preconfiguration A is used for

protection and control of the power transformer, the REF630 with preconfiguration B

protects and controls the outgoing feeder and the REF630 with preconfiguration D is

used for the bus sectionalizer.

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3. Preconfigurations

The 630 series IEDs are offered with optional

factory-made application preconfigurations.

The preconfigurations contribute to faster

commissioning and less engineering of the

IED. The preconfigurations include default

functionality typically needed for a specific

application. Each preconfiguration is

adaptable using the Protection and Control

IED Manager PCM600. By adapting the

preconfiguration the IED can be configured

to suit the particular application.

The adaptation of the preconfiguration may

include adding or removing of protection,

control and other functions according to the

specific application, changing of the default

parameter settings, configuration of the

default alarms and event recorder settings

including the texts shown in the HMI,

configuration of the LEDs and function

buttons, and adaptation of the default single-

line diagram.

In addition, the adaptation of the

preconfiguration always includes

communication engineering to configure the

communication according to the functionality

of the IED. The communication engineering

is done using the communication

configuration function of PCM600.

If none of the offered preconfigurations fulfill

the needs of the intended area of application

the 630 series IEDs can also be ordered

without any preconfiguration. This option

enables full flexibility to configure the IED

from the ground up.

Table 1. REF630 preconfigurations

Description Preconfiguration

Preconfiguration A for open/closed ring feeder A

Preconfiguration B for radial overhead/mixed line feeder B

Preconfiguration C for ring/meshed feeder C

Preconfiguration D for bus sectionalizer D

Number of instances available N

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Table 2. Supported functions

Functionality A B C D N

Protection

Three-phase non-directional overcurrent, low stage 1 1 1 1 1

Three-phase non-directional overcurrent, high stage 2 2 2 2 2

Three-phase non-directional overcurrent, instantaneous stage 1 1 1 1 1

Three-phase directional overcurrent, low stage 2 - - - 2

Three-phase directional overcurrent, high stage 1 - - - 1

Non-directional earth fault, low stage - 1 - 1 1

Non-directional earth fault, high stage 1 1 1 1 1

Non-directional earth fault, instantaneous stage - 1 - 1 1

Directional earth fault, low stage 2 1 3 - 3

Directional earth fault, high stage 1 - 1 - 1

Transient/intermittent earth fault 1 - - - 1

Negative-sequence overcurrent 2 2 2 2 2

Three-phase thermal overload for feeder 1 1 1 - 1

Phase discontinuity 1 1 1 - 1

Three-phase current inrush detection 1 1 1 1 1

Three-phase overvoltage - - 3 - 3

Three-phase undervoltage - - 3 - 3

Positive-sequence overvoltage

- - - -

Positive-sequence undervoltage

- - - -

Negative-sequence overvoltage

- - - -

Residual overvoltage - - 3 - 3

Frequency gradient - - - - 5

Overfrequency - - - - 5

Underfrequency - - - - 5

Load shedding - - - - 6

Fault locator

- - - -

Circuit-breaker failure 1 1 1 1 2

Autoreclosing 1 1 1 - 2

Tripping logic 1 1 1 1 2

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Table 2. Supported functions, continued

Functionality A B C D N

Distance protection

- - 1 -

Automatic switch-onto-fault logic - - 1 - 2

Protection related functions

Local accelerat. logic - - 1 - 1

Communication logic for residual OC - - 1 - 1

Scheme communic. logic - - 1 - 1

Current reversal and WEI logic - - 1 - 1

Current reversal and WEI logic for residual OC - - 1 - 1

Control

Bay control 1 1 1 1 1

Interlocking interface 4 4 4 1 10

Circuit-breaker/disconnector control 4 4 4 1 10

Circuit breaker 1 1 1 1 2

Disconnector 3 3 3 - 8

Local/remote switch interface - - - - 1

Synchrocheck

- - - -

Supervision and monitoring

Circuit-breaker condition monitoring 1 1 1 1 2

Fuse failure supervision 1 1 1 - 2

Current-circuit supervision 1 1 1 - 2

Trip-circuit supervision 3 3 3 3 3

Station battery supervision - - - - 1

Energy monitoring - - - - 1

Generic measured values - - - - 3

Measured value limit supervision - - - - 9

Measurement

Three-phase current 1 1 1 1 1

Three-phase voltage, phase-to-earth 1 1 1 1 1

Three-phase voltage, phase-to-phase - - - - 1

Residual current 1 1 1 1 1

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Table 2. Supported functions, continued

Functionality A B C D N

Residual voltage 1 1 1 - 1

Power monitoring with P, Q, S, power factor, frequency 1 1 1 1 1

Sequence current 1 1 1 1 1

Sequence voltage 1 1 1 1 1

Metering

Pulse counter for energy metering - - - - 4

Disturbance recorder function

Analog channels 1-10 (samples) 1 1 1 1 1

Analog channel 11-20 (samples) - - - - 1

Analog channel 21-30 (samples) - - - - 1

Analog channel 31-40 (calc val) - - - - 1

Binary channels 1-16 1 1 1 1 1

Binary channels 17-32 1 1 1 1 1

Binary channels 33-48 1 1 1 1 1

Binary channels 49-64 1 - 1 - 1

1) Optional functions, to be specified at ordering

4. Protection functions

The IED offers selective short-circuit and

overcurrent protection including three-phase

non-directional overcurrent protection with

four independent stages, and three-phase

directional overcurrent protection with three

independent stages. In addition, the IED

includes three-phase current inrush detection

for blocking selected overcurrent protection

stages or temporarily increasing the setting

values. The included thermal overload

protection function uses thermal models of

overhead lines and cables. The negative-

sequence overcurrent protection, with two

independent stages, is used for phase-

unbalance protection. In addition, the IED

offers phase discontinuity protection.

Further, the IED features selective earth-fault

and cross country fault protection for isolated

neutral, and for resistance and/or impedance

earthed neutral systems including solidly

earthed neutral systems. The earth-fault

protection includes non-directional earth-fault

protection with three independent stages and

directional earth-fault protection with four

independent stages.

The included transient/intermittent earth-fault

protection is based on detection of earth-fault

transients related to continuous or

intermittent faults. Intermittent earth-fault is

special type of earth-fault encountered in

compensated networks with underground

cables. In solidly earthed or compensated

networks the transient earth-fault protection

function detects earth-faults with low fault

resistance. The residual overvoltage

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protection, with three independent stages, is

used for earth-fault protection of the

substation bus and the incoming feeder, and

for back-up protection of the outgoing feeders.

The IED offers distance protection including

both circular (mho) and quadrilateral (quad)

zone characteristics, three independent zones

with separate reach settings for phase-to-

phase and phase-to-earth measuring elements

and two zones for controlling auto-reclosing

of circuit breakers. Further, the IED offers

automatic switch onto fault logic with voltage

and current based detection options.

The IED offers voltage protection functions

including three-phase undervoltage and

overvoltage protection with three

independent stages each, both with phase-to-

phase or phase-to-earth measurement. The

IED offers overfrequency, underfrequency

and rate-of-change of frequency protection to

be used in load shedding and network

restoration applications.

In addition the IED offers three-pole multi-

shot autoreclose functions for overhead line

feeders.

The IED incorporates breaker failure

protection for circuit breaker re-tripping or

back-up tripping for the upstream breaker.

GUID-8D94ABFF-3F94-4C26-BDF5-2F4DD4B906FB V1 EN

Figure 2. Protection function overview of preconfiguration A

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GUID-4460293F-E493-4876-8B35-EA12DD21B7BD V1 EN

Figure 3. Protection function overview of preconfiguration B

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GUID-A0FC88A2-E407-4A57-86B8-8845CE7AD078 V1 EN

Figure 4. Protection function overview of preconfiguration C

GUID-CE8BEBCD-9D9B-4FE6-A9EF-AF4690339584 V1 EN

Figure 5. Protection function overview of preconfiguration D

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5. Control

The IED incorporates local and remote

control functions. The IED offers a number of

freely assignable binary inputs/outputs and

logic circuits for establishing bay control and

interlocking functions for circuit breakers and

motor operated switch-disconnectors. The

IED supports both single and double busbar

substation busbar layouts. The number of

controllable primary apparatuses depends on

the number of available inputs and outputs in

the selected configuration. Besides

conventional hardwired signaling also

GOOSE messaging according to IEC

61850-8-1 can be used for signal interchange

between IEDs to obtain required interlockings.

Further, the IED incorporates a synchro-

check function to ensure that the voltage,

phase angle and frequency on either side of

an open circuit breaker satisfy the conditions

for safe interconnection of two networks.

6. Fault location

REF630 features an impedance-measuring

fault location function suitable for locating

short-circuits in radial distribution systems.

Earth faults can be located in effectively and

low-resistance earthed networks. Under

circumstances where the fault current

magnitude is at least of the same order of

magnitude or higher than the load current,

earth faults can also be located in isolated

neutral distribution networks. The fault

location function identifies the type of the

fault and then calculates the distance to the

fault point. An estimate of the fault resistance

value is also calculated. The estimate

provides information about the possible fault

cause and the accuracy of the estimated

distance to the fault point.

7. Measurement

The IED continuously measures the phase

currents, positive and negative sequence

currents and the residual current. The IED

also measures phase-to earth or phase-to-

phase voltages, positive and negative

sequence voltages and the residual voltage.

In addition, the IED monitors active, reactive

and apparent power, the power factor, power

demand value over a user-selectable pre-set

time frame as well as cumulative active and

reactive energy of both directions. Line

frequency, the calculated temperature of the

feeder, and the phase unbalance value based

on the ratio between the negative sequence

and positive sequence current are also

calculated. Cumulative and averaging

calculations utilize the non-volatile memory

available in the IED.

The values measured are accessed locally via

the front-panel user interface of the IED or

remotely via the communication interface of

the IED. The values are also accessed locally

or remotely using the web-browser based

user interface.

8. Disturbance recorder

The IED is provided with a disturbance

recorder featuring up to 40 analog and 64

binary signal channels. The analog channels

can be set to record the waveform of the

currents and voltage measured. The analog

channels can be set to trigger the recording

when the measured value falls below or

exceeds the set values. The binary signal

channels can be set to start a recording on

the rising or the falling edge of the binary

signal. The binary channels are set to record

external or internal IED signals, for example

the start or operate signals of the protection

functions, or external blocking or control

signals. Binary IED signals such as a

protection start or trip signal, or an external

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IED control signal over a binary input can be

set to trigger the recording. In addition, the

disturbance recorder settings include pre and

post triggering times.

The disturbance recorder can store up to 100

recordings. The number of recordings may

vary depending on the length of the

recording and the number of signals

included. The disturbance recorder controls

the Start and Trip LEDs on the front-panel

user interface. The operation of the LEDs is

fully configurable enabling activation when

one or several criteria, i.e. protection function

starting or tripping, are fulfilled.

The recorded information is stored in a non-

volatile memory and can be uploaded for

subsequent fault analysis.

9. Event log

The IED features an event log which enables

logging of event information. The event log

can be configured to log information

according to user pre-defined criteria

including IED signals. To collect sequence-of-

events (SoE) information, the IED

incorporates a non-volatile memory with a

capacity of storing 1000 events with

associated time stamps and user definable

event texts. The non-volatile memory retains

its data also in case the IED temporarily loses

its auxiliary supply. The event log facilitates

detailed pre- and post-fault analyses of faults

and disturbances.

The SoE information can be accessed locally

via the user interface on the IED front panel

or remotely via the communication interface

of the IED. The information can further be

accessed, either locally or remotely, using the

web-browser based user interface.

The logging of communication events is

determined by the used communication

protocol and the communication engineering.

The communication events are automatically

sent to station automation and SCADA

systems once the required communication

engineering has been done.

10. Disturbance report

The disturbance report includes information

collected during the fault situation. The

report includes general information such as

recording time, pre-fault time and post fault

time. Further, the report includes pre-fault

magnitude, pre-fault angle, fault magnitude

and fault angle trip values. By default, the

disturbance reports are stored in a non-

volatile memory. The numerical disturbance

report can be accessed via the local front

panel user interface. A more comprehensive

disturbance report with waveforms is

available using PCM600.

11. Circuit-breaker

monitoring

The condition monitoring functions of the

IED constantly monitors the performance and

the condition of the circuit breaker. The

monitoring comprises the spring charging

time, SF6 gas pressure, the travel-time and

the inactivity time of the circuit breaker.

The monitoring functions provide operational

CB history data, which can be used for

scheduling preventive CB maintenance.

12. Trip-circuit

supervision

The trip-circuit supervision continuously

monitors the availability and operability of

the trip circuit. It provides open-circuit

monitoring both when the circuit breaker is

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in its closed and in its open position. It also

detects loss of circuit-breaker control voltage.

13. Self-supervision

The IED’s built-in self-supervision system

continuously monitors the state of the IED

hardware and the operation of the IED

software. Any fault or malfunction detected

will be used for alerting the operator.

Self-supervision events are saved into an

internal event list which can be accessed

locally via the user interface on the IED front

panel. The event list can also be accessed

using the web-browser based user interface

or PCM600.

14. Fuse failure

supervision

The fuse failure supervision detects failures

between the voltage measurement circuit and

the IED. The failures are detected by the

negative-sequence based algorithm or by the

delta voltage and delta current algorithm.

Upon the detection of a failure the fuse

failure supervision function activates an alarm

and blocks voltage-dependent protection

functions from unintended operation.

15. Current circuit

supervision

Current circuit supervision is used for

detecting faults in the current transformer

secondary circuits. On detecting of a fault the

current circuit supervision function can also

activate an alarm LED and block certain

protection functions to avoid unintended

operation. The current circuit supervision

function calculates the sum of the phase

currents and compares the sum with the

measured single reference current from a

core balance current transformer or from

another set of phase current transformers.

16. Access control

To protect the IED from unauthorized access

and to maintain information integrity the IED

is provided with an authentication system

including user management. Using the IED

user management tool in the Protection and

Control IED Manager PCM600, an individual

password is assigned to each user by the

administrator. Further, the user name is

associated to one or more of the four

available user groups: System Operator,

Protection Engineer, Design Engineer and

User Administrator. The user group

association for each individual user enables

the use of the IED according to the profile of

the user group.

17. Inputs and outputs

Depending on the hardware configuration

selected, the IED is equipped with three phase-

current inputs and one or two residual-

current inputs for earth-fault protection. The

IED always includes one residual voltage

input for directional earth-fault protection or

residual voltage protection. Further, the IED

includes three phase-voltage inputs for

overvoltage, undervoltage and directional

overcurrent protection and other voltage

based protection functions. Depending on the

hardware configuration, the IED also includes

a dedicated voltage input for synchrocheck.

The phase-current inputs are rated 1/5 A. The

IED is equipped with one or two alternative

residual-current inputs, that is 1/5 A or

0.1/0.5 A. The 0.1/0.5 A input is normally

used in applications requiring sensitive earth-

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fault protection and featuring a core-balance

current transformer.

The three phase-voltage inputs, for either

phase-to-phase voltages or phase-to-earth

voltages, and the residual-voltage input cover

the rated voltages 100 V, 110 V, 115 V and

120 V. The rated values of the current and

voltage inputs are selected in the IED software.

In addition, the binary input thresholds are

selected by adjusting the IED’s parameter

settings. The threshold voltage can be set

separately for each binary input.

All binary input and output contacts are

freely configurable using the signal matrix of

the application condiguration function in

PCM600.

Please refer to the Input/output overview

tables, the selection and ordering data and

the terminal diagrams for more detailed

information about the inputs and outputs.

Table 3. Analog input options

Analog input

configuration

CT (1/5 A) CT sensitive

(0.1/0.5 A)

AA 4 - 5

AB 4 1 4

AC 3 1 5

Table 4. Binary input/output options

Binary input options

BI BO

Default 14 9

With one optional binary I/O

module

23 18

With two optional binary I/O

modules

32 27

18. Communication

The IED supports the new IEC 61850

substation automation standard including

horizontal GOOSE communication as well as

the well-established DNP3 (TCP/IP) protocol.

All operational information and controls are

available through these protocols.

Disturbance files are accessed using the IEC

61850 protocol. Disturbance files are

available to any Ethernet based application in

the standard COMTRADE format. Further, the

IED sends and receives binary signals from

other IEDs using the IEC 61850-8-1 GOOSE

profile. The IED meets the GOOSE

performance requirements for tripping

applications in distribution substations, as

defined by the IEC 61850 standard. The IED

interoperates with other IEC 61850 compliant

IEDs, tools and systems and simultaneously

reports events to five different clients on the

IEC 61850 station bus. For a system using

DNP3 over TCP/IP, events can be sent to four

different masters.

All communication connectors, except for the

front port connector, are placed on integrated

communication modules. The IED is

connected to Ethernet-based communication

systems via the RJ-45 connector (10/100BASE-

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TX) or the fibre-optic multimode LC

connector (100BASE-FX).

The IED supports SNTP, DNP3 and IRIG-B

time synchronization methods with a time-

stamping resolution of 1 ms.

Ethernet based:

• SNTP (Simple Network Time Protocol)

• DNP3

With special time synchronization wiring:

• IRIG-B (Inter-Range Instrumentation Group

- Time Code Format B)

Table 5. Supported communication interface and protocol alternatives

Interfaces/Protocols

Ethernet

100BASE-TX RJ-45

Ethernet

100BASE-FX LC

IEC 61850

● ●

DNP3

● ●

● = Supported

1) Please refer to the Selection and ordering data chapter for more information

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19. Technical data

Table 6. Dimensions

Description Type Value

Width half 19" 220 mm

Height half 19" 177 mm (4U)

Depth half 19" 249.5 mm

Weight half 19" box 6.2 kg (4U)

half 19" LHMI 1.0 kg (4U)

Table 7. Power supply

Description

Type 1 Type 2

aux

nominal 100, 110, 120, 220, 240 V

AC, 50 and 60 Hz

48, 60, 110, 125 V DC

110, 125, 220, 250 V DC

aux

variation 85...110% of U

(85...264 V

AC)

80...120% of U

(38.4...150 V

DC)

80...120% of U

(88...300 V

DC)

Maximum load of auxiliary

voltage supply

35 W

Ripple in the DC auxiliary

voltage

Max 15% of the DC value (at frequency of 100 Hz)

Maximum interruption time in

the auxiliary DC voltage

without resetting the IED

50 ms at U

aux

Power supply input must be

protected by an external

miniature circuit breaker

For example, type S282 UC-K

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Table 8. Energizing inputs

Description Value

Rated frequency 50/60 Hz

Operating range Rated frequency ± 5 Hz

Current inputs Rated current, I

0.1/0.5 A

1/5 A

Thermal withstand

capability:

• Continuously 4 A 20 A

• For 1 s 100 A 500 A

• For 10 s 20 A 100 A

Dynamic current

withstand:

• Half-wave value 250 A 1250 A

Input impedance <100 mΩ <20 mΩ

Voltage inputs Rated voltage 100 V/ 110 V/ 115 V/ 120 V (Parametrization)

Voltage withstand:

• Continuous 425 V

• For 10 s 450 V

Burden at rated voltage <0.05 VA

1) Residual current

2) Phase currents or residual current

Table 9. Binary inputs

Description

Value

Operating range Maximum input voltage 300 V DC

Rated voltage 24...250 V DC

Current drain 1.6...1.8 mA

Power consumption/input <0.3 W

Threshold voltage 15...221 V DC (parametrizable in the range in

steps of 1% of the rated voltage)

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Table 10. Signal output and IRF output

IRF relay change over - type signal output relay

Description Value

Rated voltage 250 V AC/DC

Continuous contact carry 5 A

Make and carry for 3.0 s 10 A

Make and carry 0.5 s 15 A

Breaking capacity when the control-circuit

time constant L/R<40 ms, at U< 48/110/220

V DC

≤0.5 A/≤0.1 A/≤0.04 A

Minimum contact load 100 mA at 24 V AC/DC

Table 11. Power output relays, with or without TCS function

Description

Value

Rated voltage 250 V AC/DC

Continuous contact carry 8 A

Make and carry for 3.0 s 15 A

Make and carry for 0.5 s 30 A

Breaking capacity when the control-circuit

time constant L/R<40 ms, at U< 48/110/220

V DC

≤1 A/≤0.3 A/≤0.1 A

Minimum contact load 100 mA at 24 V AC/DC

Table 12. Power output relays with TCS function

Description

Value

Control voltage range 20...250 V DC

Current drain through the supervision circuit ~1.0 mA

Minimum voltage over the TCS contact 20 V DC

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Table 13. Ethernet interfaces

Ethernet interface Protocol Cable Data transfer rate

LAN/HMI port (X0)

- CAT 6 S/FTP or better 100 MBits/s

LAN1 (X1) TCP/IP protocol Shielded twisted pair

CAT 5e cable with

RJ-45 connector or

fibre-optic cable with

LC connector

100 MBits/s

1) Only available for the external HMI option.

Table 14. Fibre-optic communication link

Wave length

Fibre type Connector Permitted path

attenuation

Distance

1300 nm MM 62.5/125

μm glass

fibre core

LC <8 dB 2 km

1) Maximum allowed attenuation caused by connectors and cable together

Table 15. X4/IRIG-B interface

Type

Protocol Cable

Screw terminal, pin

row header

IRIG-B Shielded twisted pair cable

Recommended: CAT 5, Belden RS-485 (9841-

9844) or Alpha Wire (Alpha 6222-6230)

Table 16. Serial rear interface

Type

Counter connector

Serial port (X9) Optical ST connector or optical snap-in

connector

1) For future use

Table 17. Degree of protection of flush-mounted IED

Description

Value

Front side IP 40

Rear side, connection terminals IP 20

Table 18. Degree of protection of the LHMI

Description

Value

Front and side IP 42

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